Stabilizing downhole tool

ABSTRACT

Embodiments disclosed herein relate to a downhole tool and a method to abate vibration with the downhole tool. The downhole tool may include a first stabilizing member, a second stabilizing member, a flexible member, and/or a dampening member, in which the downhole tool may be disposed downhole within a wellbore. The flexible member may enable the first stabilizing member and the second stabilizing member to articulate with respect to an axis of the downhole tool. The dampening member may enable vibration received by the downhole tool to be dampened. Further, the first stabilizing member and the second stabilizing member may be rotatable with respect to each other about the axis of the downhole tool.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims benefit, under 35 U.S.C. §119, of U.S.Provisional Application Ser. No. 61/220,474 filed on Jun. 25, 2009 andentitled “Stabilizing Downhole Tool” in the name of George Swietlik andBurney Latiolais. The disclosure of this U.S. Provisional Application isincorporated herein by reference in its entirety.

BACKGROUND OF DISCLOSURE

1. Field of the Disclosure

Embodiments disclosed herein generally relate to methods and tools to bedisposed downhole within a string of tubular members. More specifically,embodiments disclosed herein relate to a downhole tool to be connectedwithin a string of tubular members, in which the downhole tool may beused to assist in stabilizing the string.

2. Background Art

In oilfield exploration and production operations, various oilfieldtubulars are used to perform important tasks, including, but not limitedto, drilling a borehole (or wellbore) and casing the drilled borehole.For example, a string of tubular members, known in the industry as adrill string, may be used to advance and/or rotate a drill bit at adistal end to create the borehole. As used herein, the term drill stringmay be used to describe any string of tubular members used to rotateand/or advance a drill bit including, but not limited to, strings ofdrill pipe, drill collars, premium threaded connections, casing joints,and coiled tubing.

Furthermore, after a borehole has been created, a casing string may bedisposed downhole into the borehole and cemented in place (or merelycemented in-situ where casing is used as the drill string) to stabilize,reinforce, or isolate (among other functions) portions of the borehole.As such, tubular strings may be connected together, end-to-end bythreaded connections, where a female “pin” member of a first tubular isconfigured to threadably engage a corresponding male “box” member of asecond tubular. Alternatively, a tubular string may be made-up of a ofmale-male ended joints coupled together by female-female couplers. Theprocess by which the threaded connections are screwed together is called“making-up” a threaded joint, and the process by which the connectionsare disassembled is referred to as “breaking-out” the threaded joint. Aswould be understood by one having ordinary skill, individual pieces (or“joints”) of oilfield tubulars may come in a variety of materials,weights, diameters, configurations, and lengths.

As such, in the drilling, completing, or reworking of oil wells, avariety of downhole tools may be used. FIG. 1 shows one example of aconventional drilling system 100 for drilling an earth formation. Thedrilling system includes a drilling rig 110 that may lift, lower and/orturn a drilling tool assembly 112 extending downward into a borehole114. Drilling tool assembly 112 generally includes a drill string 116with a bottom hole assembly 118 having a drill bit 120 attached to adistal end of drill string 116.

The drill string 116 may include several joints of drill pipe 116Aconnected end-to-end through one or more tool joints 116B. The drillstring 116 may be connected such that the drill pipe 116A is tightenedto a certain amount, such as to a specific torque. The drill string 116may also be disconnected such that the drill pipe 116A is threadablytaken apart. The drill string 116 may transmit drilling fluid (such asthrough a central bore) and/or rotational torque from the drill rig 110to the bottom hole assembly 118. The drill pipe 116A may provide ahydraulic passage through which drilling fluid (e.g., mud) is pumped.The drilling fluid typically discharges through selected-size orificesin the bit (e.g., “jets”) for the purposes of cooling the drill bit 120and lifting rock cuttings out of borehole 114 as it is drilled.Similarly, rather than using drilling mud, the drill string 116 may beused to transmit air, such as when air drilling, in which the air isused to lift rock cuttings out of the borehole 114.

The bottom hole assembly 118 may include the drill bit 120, in additionto other components that may be attached between the drill string 116and drill bit 120. Examples of additional downhole, e.g., bottom holeassembly, components may include, but are not limited to, drill collars,stabilizers, transducers, measurement-while-drilling tools,logging-while-drilling tools), downhole motors (e.g., mud motors), orany combination thereof.

During drilling, axial, lateral, and/or rotational vibration (e.g.,movement, oscillations, etc.) may be imparted to the drill bit 120 anddrill string 116 (including bottom hole assembly 118) from variousdownhole (and surface) forces. For example, as the drill bit 120compacts and cuts the earth formation, the cutting forces may impartvibration to the drill bit 120, the bottom hole assembly 118, and/or thedrill string 116. Additionally, the rotation and/or axial displacementof the drill string 116 may further impart vibration to the drill stringcomponents (116, 118, and 120) from the forces generated by the rotatingdrill string 116 contacting the borehole and other downhole components.Furthermore, if the bottom hole assembly 118 is so equipped, a downholemud motor (e.g., progressive cavity positive displacement mud motors orturbo drills) may impart vibration to the drill bit 120 and drill string116 (including other components of bottom hole assembly 118) from theforces generated by their operation.

Vibration may cause the drilling apparatus, including drill string 116,bottom hole assembly 118, and drill bit 120, to bend, twist, bounce, orotherwise deviate off-course, such as having the borehole formed largerthan desired or having the trajectory of the borehole formed off-courseand generate poor borehole quality. Thus, vibration may inhibit a moreefficient excavation of the subterranean formation by the drilling rig100. Further, vibration may cause damage to one or more of the drillstring components (116, 118, and 120) and any downhole componentsdisposed therein. For example, a sensor may be included with a bottomhole assembly 118, in which the sensor may be used for measuring and/orsensing one or more downhole parameters, e.g., drilling parameters.Vibration received therein may damage a sensor and/or interfere with thecorrect operation of the sensor. Vibration may interfere with thelogging, recordation, and/or transmittal of information (e.g., from adownhole sensor) to and/or from the drilling rig 100, in addition tointerfering with the performance of the bottom hole assembly 118, andpossibly drill string components (116, 118, and 120), altogether.Accordingly, there exists a need to increase the stability of, as wellas reduce downhole vibration imparted to, at least a portion of drillstrings, drill bits, and bottom hole assemblies.

Additionally, there also exists a need to more effectively maintaincontact between the cutting surface of a drill bit and an earthformation during drilling. Drill bit 120 vibration, particularly duringcutting, may damage or prematurely wear drill bit 120. Furthermore,vibration may cause the drill bit 120, for example, to lift off of thebottom of the borehole, thereby reducing the bit's rate of penetrationinto a formation. As such, there exists a need to dampen the vibrationof a drill string, for example, a portion of the drill string (includingbottom hole assembly and/or drill bit components) in a drilling system.

SUMMARY OF INVENTION

In a first aspect, embodiments disclosed herein relate to a method toabate vibration within a borehole. The method includes connecting adownhole tool within a string of tubular members, the string of tubularmembers having a drill bit disposed at one end, and disposing thedownhole tool having an axis defined therethrough within the borehole,the downhole tool having a first stabilizing member, a secondstabilizing member, and a flexible member. The method further includesflexing the flexible member such that one of the first stabilizingmember and the second stabilizing member contacts a wall of theborehole, and drilling into the borehole with the drill bit.

In another aspect, embodiments disclosed herein relate to a method toabate vibration within a borehole. The method includes connecting adownhole tool within a string of tubular members, the string of tubularmembers having a drill bit disposed at one end, and disposing thedownhole tool having an axis defined therethrough within the borehole,the downhole tool having a first stabilizing member located above aflexible member. The method further includes flexing the flexible membersuch that one of the first stabilizing member and the second stabilizingmember contacts a wall of the borehole, and drilling into the boreholewith the drill bit.

In another aspect, embodiments disclosed herein relate to a method toabate vibration within a borehole. The method includes connecting adownhole tool within a string of tubular members, the string of tubularmembers having a drill bit disposed at one end, and disposing thedownhole tool having an axis defined therethrough within the borehole,the downhole tool comprising a first stabilizing member and a dampeningmember. The method further includes dampening vibration received withinthe downhole tool with the dampening member, and drilling into theborehole with the drill bit.

In another aspect, embodiments disclosed herein relate to a downholetool to abate vibration. The downhole tool includes a generally tubularbody having an axis defined therethrough, a first stabilizing memberdisposed at a first location on the tubular body, a second stabilizingmember disposed at a second location on the tubular body, in which thefirst stabilizing member and the second stabilizing member are rotatablewith respect to each other about the axis, and a flexible memberdisposed within the tubular body such that the first stabilizing memberand the second stabilizing member are configured to articulate withrespect to each other along the axis.

In another aspect, embodiments disclosed herein relate to a downholetool having an axis defined therethrough to be disposed within aborehole. The downhole tool includes a first stabilizing member disposedat a first location and a second stabilizing member disposed at a secondlocation. The first stabilizing member and the second stabilizing memberare rotatable with respect to each other about the axis, and the firststabilizing member and the second stabilizing member are each configuredto engage a wall of the borehole.

In another aspect, embodiments disclosed herein relate to a systemhaving an axis defined therethrough to be disposed within a borehole.The system includes a downhole tool having a first end and a second end,the downhole tool including a first stabilizing member having adampening member disposed thereon, a second stabilizing member, whereinthe first stabilizing member and the second stabilizing member arerotatable with respect to each other about the axis, and a flexiblemember disposed within the tubular member such that the firststabilizing member and the second stabilizing member are configured toarticulate with respect to each other along the axis. The system furtherincludes an upper bottom hole assembly having a first end and a secondend, in which the second end of the upper bottom hole assembly isconnected to the first end of the downhole tool, and a lower bottom holeassembly having a first end and a second end, in which the first end ofthe lower bottom hole assembly is connected to the second end of thedownhole tool.

Other aspects and advantages of the invention will be apparent from thefollowing description and the appended claims.

BRIEF DESCRIPTION OF DRAWINGS

FIG. 1 is a schematic view of a drilling rig.

FIGS. 2A, 2B, and 2C show multiple perspective views of a downhole toolin accordance with an embodiment of the present disclosure.

FIG. 3A shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 3B shows a detailed perspective view of a flexible member inaccordance with an embodiment of the present disclosure.

FIG. 4 shows a perspective view of a downhole tool within a string oftubular members in accordance with an embodiment of the presentdisclosure.

FIG. 5 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 6 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 7 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 8 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 9 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 10 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 11 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

FIG. 12 shows a cross-sectional view of a downhole tool in accordancewith an embodiment of the present disclosure.

DETAILED DESCRIPTION

Embodiments of the present disclosure will now be described in detailwith reference to the accompanying Figures. Like elements in the variousfigures may be denoted by like reference numerals for consistency.Further, in the following detailed description of embodiments of thepresent disclosure, numerous specific details are set forth in order toprovide a more thorough understanding of the claimed subject matter.However, it will be apparent to one of ordinary skill in the art thatthe embodiments disclosed herein may be practiced without these specificdetails. In other instances, well-known features have not been describedin detail to avoid unnecessarily complicating the description.Additionally, it will be apparent to one of ordinary skill in the artthat the scale of the elements presented in the accompanying Figures mayvary without departing from the scope of the present disclosure.

As used herein, a “drill bit” refers to any tool, mechanism, device,and/or instrument that may be used to cut, shear, drill, bore, puncture,penetrate, and/or use any other method known in the art to remove earthwhen forming a borehole within a formation. For example, a drill bit mayinclude one or more of a roller-cone drill bit, a shearing drill bit, arock bit, a PDC (polycrystalline diamond compact) bit, a reamer, amilling tool, and/or any other device or tool known in the art. A drillbit may further include one or more of a cutting element, a shearingelement, a compression element, a PCD (polycrystalline diamond) element,and/or any other element known in the art.

Furthermore, as used herein, “drilling” may refer to any procedureand/or method that may be used to remove earth, such as when formingand/or enlarging a borehole, but may also include other methods andprocedures performed during the course of drilling, extending, and/orenlarging a borehole, such as when removing devices and/or componentsthat may be disposed downhole. For example, “drilling” may include theremoval of one or more packer elements, the removal of one or moretubular members, and/or the removal of other materials and/or devicesdisposed within a formation, such as by milling to remove a packerelement disposed within a formation during a work over of borehole.Accordingly, the present disclosure contemplates using differentstructures and types of drill bits in one or more methods when drillingand forming a borehole.

In various aspects disclosed herein, embodiments disclosed hereingenerally relate to a downhole tool to be used within a drill string andto be disposed downhole within a borehole. The downhole tool may be usedto stabilize, or assist in stabilizing, one or more tubular members whenthe tubular members are disposed downhole within a borehole.Particularly, the downhole tool may be disposed downhole within aborehole, such as having the tool connected within a string of tubularmembers disposed downhole, in which the downhole tool may engage one ormore surfaces of the borehole. Further, the downhole tool may abatevibration (e.g., reduce vibration, reduce the transfer of vibrationacross the tool, or stop the transfer of vibration across the tool), forexample, vibration received during drilling and/or rotation of a drillstring. As used herein, vibration may refer to any movement, force,and/or oscillation received by a downhole tool in the axial, radial,and/or rotational directions. As such, the downhole tool may preventdamage to the drillstring, bottom hole assembly, or any other downholetools disposed within the borehole or attached to a tubular string.

Thus, in one aspect, a downhole tool in accordance with one or moreembodiments of the present disclosure may include a generally tubularbody having an axis defined therethrough. A first stabilizing member maybe disposed at one location on the tubular body, and an optional secondstabilizing member may be disposed at another location on the tubularbody. In this arrangement, the first stabilizing member and the secondstabilizing member may be able to rotate with respect to each otherabout the axis of the tubular body. The downhole tool may also include aflexible member disposed therein, in which the flexible member mayenable the first stabilizing member and the second stabilizing member tobe able to deflect (e.g., flex or articulate) with respect to each otheralong their respective axes. As such, the first stabilizing memberand/or the second stabilizing member may be able to engage a wall of aborehole and provide stabilization to the downhole tool.

Further, the downhole tool may additionally have a dampening member. Forexample, the downhole tool may have a dampening member includedtherewith. The dampening member may be used to dampen vibration in oneor more directions, such as dampen vibration in the axial, radial,and/or rotational direction. As such, when dampening vibration primarilyin the axial direction, the dampening member may include, for example, a“shock sub” assembly. In such an embodiment, the shock sub assembly maybe disposed within the downhole tool. Those having ordinary skill in theart, though, will appreciate that other dampening members may be used todampen vibration in one or more directions without departing from thescope of the present disclosure.

The downhole tool may include a dampening member disposed between afirst stabilizing member and a second stabilizing member. Further, thedownhole tool may have a dampening member disposed on or adjacent to thefirst stabilizing member and/or second stabilizing member. For example,the dampening member may be disposed upon an outer surface of astabilizing member, and/or the dampening member may be disposed betweenan outer surface of a stabilizing member and an inner bore of thedownhole tool. The dampening member may include a dampening material,such as by having the dampening material disposed between the firststabilizing member and the second stabilizing member, disposed on awellbore contacting surface of the first stabilizing member and/or thesecond stabilizing member, and/or disposed within the first stabilizingmember and/or the second stabilizing member. The dampening member maydampen (e.g., reduce) vibration received by components of the drillstring (including the bottom hole assembly, e.g., sensors therein, andthe drill bit), such as by reducing at least a portion of the vibrationreceived within the dampening member, thereby reducing vibrationreceived within the downhole tool and/or other components of the drillstring. In various embodiments disclosed herein, the dampening membermay include an elastomeric member and/or an elastomeric material.Further, the downhole tool may be disposed with a bottom hole assembly,for example, disposed between an upper bottom hole assembly and a lowerbottom hole assembly. In such embodiments, a downhole tool in accordancewith embodiments disclosed herein may dampen vibration within the bottomhole assembly, for example, between the upper bottom hole assembly(which may include a downhole component, e.g., sensor) and the lowerbottom hole assembly.

Referring now to FIGS. 2A and 2B, multiple perspective views of adownhole tool 201 in accordance with embodiments disclosed herein areshown. Particularly, FIG. 2A shows an outlined perspective view of thedownhole tool 201, and FIG. 2B shows a textured perspective view of thedownhole tool 201. The illustrated downhole tool 201 includes agenerally tubular body 203 having an axis 205 defined therethrough. Assuch, a bore may be defined within the body 203 that extends through thebody 203 of the downhole tool 201, such as to induce fluid flow throughthe downhole tool 201. Additionally, as shown, the tubular body 203 ofthe downhole tool 201 may include one or more body portions. In thisembodiment, the downhole tool 201 includes a first body portion 207 anda second body portion 209. However, those having ordinary skill in theart will appreciate that a downhole tool in accordance with embodimentsdisclosed herein may include more than two body portions, as shown, ormay include a single body portion (e.g., with a flexible member).

Further, the downhole tool 201 may include one or more stabilizingmembers disposed thereon and/or attached thereto. As used herein, theterm “stabilizing member” refers to a location along the outer profileof the drill string (including bottom hole assembly) having a relativelyincreased outer profile, e.g., outer diameter. For example, stabilizersmay be constructed as having multi-blade, longitudinally straightmembers, as having multi-blade, radially straight members, or as havingsingle or multi-bladed spiral (helical) shaped members. As such, thebladed members may be disposed or constructed on the outer surface ofthe stabilizing members, thereby providing a surface for engagement ofthe stabilizing members with a wall of a borehole (as discussed morebelow). Regardless of particular configuration, stabilizing memberstypically function to contact the inner profile of the borehole wall (orthe inner diameter of a cased borehole) such that adjoining portions ofthe drill string (or bottom hole assembly) will not contact the boreholewall. The desire to prevent components of the drillstring or bottom holeassembly from contacting the borehole wall may come from a variety orreasons, including, but not limited to, creating a desired offset fromthe borehole for a particular measurement device and protecting an outerstructure the drilling apparatus that might otherwise become damaged ifit were allowed to contact the borehole wall. As described herein, astabilizing member may act as a grounding point(s) in a downhole toolsuch that the drill string and/or bottom hole assembly may engage a wallof the borehole to flex about a single stabilizing member or between twoor more stabilizing members.

For example, as shown in FIGS. 2A and 2B, the downhole tool 201 includesa first stabilizing member 211 and a second stabilizing member 213.Specifically, in this embodiment, the first stabilizing member 211 isdisposed on the first body portion 207, and the second stabilizingmember 213 is disposed on the second body portion 209. As such, thefirst stabilizing member 211 and the second stabilizing member 213 maybe used to stabilize the downhole tool 201, such as when disposeddownhole and/or attached to a string of tubular members (discussed morebelow) by having the stabilizing members engage the wall of a borehole.Thus, as shown, the downhole tool 201 may have at least twopoints-of-contact to engage the wall of the borehole, in which onepoint-of-contact by the first stabilizing member 211 may be axiallyspaced along the axis 205 from another point-of-contact by the secondstabilizing member 213. However, those having ordinary skill in the artwill appreciate that a downhole tool in accordance with embodimentsdisclosed herein may include more than two stabilizing members disposedthereon and/or attached thereto. Alternatively, those having ordinaryskill will appreciate that a downhole tool in accordance withembodiments disclosed herein may include a single stabilizing memberdisposed thereupon.

A stabilizing member may be rotationally fixed or rotatable relative tothe body portion it is connected to, e.g., be rotationally stationaryrelative to a borehole. In accordance with embodiments disclosed herein,dual stabilizing members and may be rotatable with respect to each otherabout the axis of the downhole tool. For example, as shown in FIGS. 2Aand 2B, the first stabilizing member 211 may be able to rotate, e.g.,about the axis 205, with respect to the second stabilizing member 213.More particularly, the body 203 of the downhole tool 201 may be able torotate between the first body section 207 and the second body section209, thereby enabling rotation between the first stabilizing member 211and the second stabilizing member 213. In this embodiment, the firstbody section 207 and the second body section 209 may be able to rotatewith respect to each other through the use of, for example, a bearingbeing disposed therebetween. However, those having ordinary skill in theart will appreciate that other mechanisms may be used to enable rotationbetween the body sections and/or the stabilizing members in accordancewith embodiments disclosed herein.

Additionally, an outer diameter of one or more of the stabilizingmembers may be larger than an outer diameter of the remainder of thetubular body of the downhole tool. For example, as shown in FIGS. 2A and2B, the outer diameter of the first stabilizing member 211 and thesecond stabilizing member 213 is larger than the outer diameter of theremainder of the tubular body 203. Further, an outer diameter of one ofthe stabilizing members may be larger than an outer diameter of theother stabilizing members. For example, with reference to FIGS. 2A and2B, the outer diameter of the first stabilizing member 211 may be largerthan the outer diameter of the second stabilizing member 213. In such anembodiment, the first stabilizing member 211 may engage and contact awall of a borehole before the second stabilizing member 213 engages andcontact the wall of the borehole. As such, in an embodiment in which aborehole has a diameter of at least about 8.75 inches (22.2 cm), thesecond stabilizing member 213 may have an outer diameter of about 8.5inches (21.6 cm), and the first stabilizing member 211 may have an outerdiameter of about 8.625 inches (21.9 cm). Further, in anotherembodiment, the outer diameter of the second stabilizing member 213 maybe larger than the outer diameter of the first stabilizing member 211.

One or more of the stabilizing members of a downhole tool in accordancewith embodiments disclosed herein may include one or more bladed membersdisposed thereon and/or attached thereto. As shown, the firststabilizing member 211 includes a plurality of bladed members 215 formedthereon and disposed radially thereabout, and the second stabilizingmember 213 includes a plurality of bladed members 217 formed thereon anddisposed radially thereabout. In such an embodiment, the bladed members215 and 217 may be used to engage and contact a wall of a borehole,thereby providing stabilization to the downhole tool 201.

Further, the downhole tool 201 may include one or more dampeningmembers, e.g., disposed thereon and/or attached thereto. Morespecifically, one or more of the stabilizing members 211 and 213 of thedownhole tool 201 may include one or more dampening members, e.g.,disposed thereon and/or attached thereto. For example, as shown in FIGS.2A and 2B, the plurality of bladed members 215 of the first stabilizingmember 211 each includes a dampening member 219 formed thereon. As usedherein, a dampening member refers to a member that may be configured todampen vibration (e.g., reduce vibration, movement, and/or energy), suchas by having the dampening member stabilize the downhole tool against aborehole wall for dampening. As shown, though only the first stabilizingmember 211 includes a dampening member 219 in FIGS. 2A and 2B, thosehaving ordinary skill in the art will appreciate that the secondstabilizing member 213 may additionally or alternatively include adampening member in accordance with embodiments disclosed herein.

The dampening member may be formed from any dampening material and/ormechanism known in the art. For example, in FIGS. 2A and 2B, the bladedmembers 215 of the first stabilizing member 211 may include a dampeningmaterial, such as an elastomeric material, in which the dampeningmaterial of the bladed members 215 may engage a borehole wall to providestabilization to the downhole tool 201, e.g., a dampening material onthe outer surface of the bladed members 215.

Further, in another embodiment, a stabilizing member of a downhole toolin accordance with embodiments disclosed herein may include a dampeningmember disposed within a stabilizing member. For example, with referenceto FIG. 2C, a detailed cross-sectional view of a stabilizing member 211in accordance with embodiments disclosed herein is shown. In thisembodiment, rather than having a dampening member 219 formed upon thestabilizing member 211, the dampening member 219 is disposed within thestabilizing member 211. The dampening member 219 may still dampenvibration, such as dampen vibration within the stabilizing member 211when engaging a wall of a borehole. Additionally, when disposing adampening member upon the downhole tool and within the stabilizingmember, the dampening member 219 may be fixed to the body section of thedownhole tool, or alternatively, the dampening member may be rotatableabout the body section of the downhole tool.

Furthermore, in accordance with one or more embodiments disclosedherein, the downhole tool may additionally, or alternatively, have adampening member disposed within the body of the downhole tool. Moreparticularly, the downhole tool may have a dampening member disposedwithin the downhole tool between the first stabilizing member and thesecond stabilizing member. For example, in one embodiment, the firststabilizing member may be able to move along and/or about the axis ofthe tool with respect to the second stabilizing member. As such, adampening member may be disposed between the first stabilizing memberand the second stabilizing member to dampen vibration therebetween. Thedampening member may include an elastomeric material, as describedabove, a biasing mechanism (e.g., a spring), and/or any other dampeningmaterial and/or mechanism known in the art. For example, the dampeningmember may include a cavity, such as a fluid cavity, in which the cavitymay be used to dampen vibration received therein. Those having ordinaryskill in the art will also appreciate that a dampening member may bedisposed in other locations of a downhole tool in accordance withembodiments disclosed herein with departing from the scope of thepresent disclosure. For example, a downhole tool having only onestabilizing member, rather than two stabilizing members as shown inFIGS. 2A and 2B, may include a dampening member disposed within the bodyof the downhole tool, such as at the location or adjacent to thestabilizing member, without departing from the scope of the presentdisclosure.

Furthermore still, one or more bladed members may include one or morepads disposed thereon and/or attached thereto, thereby providingprotection for the stabilizing members. For example, in FIGS. 2A and 2B,the bladed members 217 of the second stabilizing member 213 may includea protection member, e.g., one or more pads 221 (a plurality of pads 221as shown in this embodiment) disposed thereon, e.g., in which the pads221 may be used to engage the borehole wall. In this embodiment, thepads 221 may provide protection to the second stabilizing member 213,such as by preventing, or assist in preventing, wear to the secondstabilizing member 213 when engaging a borehole wall. Those havingordinary skill in the art will also appreciate that other protectionmembers may be added to one or more of the stabilizing members of adownhole tool in accordance with embodiments disclosed herein withoutdeparting from the present disclosure.

Referring now to FIG. 3A, a cross-sectional view of a downhole tool 301in accordance with embodiments disclosed herein is shown. Similar toabove, the downhole tool 301 includes a tubular body 303 having a firstbody portion 307 and a second body portion 309 with a first stabilizingmember 311 and a second stabilizing member 313 disposed thereon,respectively. The first stabilizing member 311 may rotate with respectto the second stabilizing member 313 about an axis 305 of the downholetool 301.

Further, a downhole tool in accordance with embodiments disclosed hereinmay have a flexible member, such as by having a flexible member disposedtherein. With reference to FIG. 3A, the downhole tool 301 includes aflexible member 331, in which the flexible member 331 may be disposedwithin the tubular body 303. For example, as shown, the flexible member331 may be disposed particularly within the second body portion 309 ofthe downhole tool 301. FIG. 3B provides a detailed perspective view ofthe flexible member 331 shown in FIG. 3A. The flexible member 331 mayenable the first stabilizing member 311 to flex (e.g., bend) along theaxis 305 of the downhole tool 301 with respect to the second stabilizingmember 313.

In the embodiment shown in FIGS. 3A and 3B, the second body portion 309may include a first body member 323 and a second body member 325, inwhich the flexible member 331 may be disposed within the second bodyportion 309 between the first body member 323 and the second body member325. As such, the flexible member 331 may enable the first body member323 and the second body member 325 to flex (e.g., bend) with respect toeach other along the axis 305, thereby enabling the first stabilizingmember 311 and the second stabilizing member 313 to rotate with respectto each other along the axis 305. Particularly, in one or moreembodiments, the flexible member 331 may enable the first body member323 and the second body member 325 to flex across substantially 360degrees about the axis 305 with respect to each other. For example, thefirst body member 323 may flex in substantially every direction aboutthe axis 305 with respect to the second body member 325. However, thosehaving ordinary skill in the art will appreciate that the embodimentsdisclosed herein are not so limited, in which other flexible members maybe used with departing from the scope of the present disclosure.

A flexible member in accordance with embodiments disclosed herein mayinclude and/or be formed from a flexible material. For example, in FIGS.3A and 3B, the flexible member 331 may include an elastomeric material337, in which the elastomeric material may allow the downhole tool 301to flex along the axis 305. The elastomeric material 337 may be disposedin one or more locations within the flexible member 331. For example, asshown in FIG. 3B, the elastomeric material 337 may be disposed adjacentto the first body member 323 and the second stabilizing member 313, inwhich the second stabilizing member 313 is attached to the second bodymember 325. Further, elastomeric material 340 may also be disposedadjacent to teeth 339 of the flexible member 331. As such, theelastomeric material 337 may allow the flexible member 331, and, thus,the downhole tool 301, to flex along the axis 305 thereof. Additionally,the elastomeric material 337 may be used to provide support (e.g., todampen) in the axial and/or radial direction of the flexible member 331with respect to the axis 305 of the downhole tool 301. Those havingordinary skill in the art, however, will appreciate that other flexiblematerials and/or locations of the flexible materials may be used withinthe flexible member in FIGS. 3A and 3B without departing from the scopeof the present disclosure. For example, as shown in FIG. 3B, theflexible member 331 may include elastomeric material 338 disposed at thelower end of the flexible member with departing from the scope of thepresent disclosure.

The dampening of flexure, e.g., dampening of the flexure in flexiblemember 331 by elastomeric material 337, 338, and/or 340, e.g., theelastomeric material 337 radially disposed about axis 305 of thedownhole tool 301, as depicted, may abate vibration, e.g., abatevibration transmitted across the flexible member 331. As discussedabove, elastomeric material may also be utilized to dampen axialmovement, e.g., an axial dampening member. For example, elastomericmaterial may be disposed between axially spaced components to dampenaxial vibration.

The teeth 339 of the flexible member 331 may be used to translate torquefrom the first body member 323 to the second body member 325, such as byhaving the teeth 339 engage recesses formed within an inner surface ofthe second stabilizing member 313, or vice versa. Teeth 339 may have anarcuate and/or rounded surface formed thereon, as shown in FIG. 3B, inwhich the teeth 339 may enable the flexing within the flexible member331 between the first body member 323 and the second body member 325.

Further, the flexible member within the downhole tool of the presentdisclosure may include a straightening member disposed therein, in whichthe straightening member may be used to provide rigidity (e.g.,restoring force) within the flexible member. For example, as shown inFIGS. 3A and 3B, the flexible member 331 may include a straighteningmember 335 disposed within the downhole tool 401. In this embodiment,the straightening member 335 is a spring beam formed as a tubularmember, in which the straightening member 335 extends from the firstbody member 323 to the second body member 325 of the second body portion309 and enables fluid flow therebetween. However, those having ordinaryskill in the art will appreciate that another straightening member mayused within the downhole tool to provide rigidity to the flexible memberof the downhole tool without departing from the scope of the presentdisclosure.

Furthermore, those having ordinary skill in the art will appreciate thatother flexible members may used within the downhole tool to enable arotation of the stabilizing members with respect to each other along theaxis of the downhole tool without departing from the scope of thepresent disclosure. For example, in another embodiment, one or moreswivels, joints, intersections for flexure and/or other flexible membersmay be included within a downhole tool in accordance with embodimentsdisclosed herein to provide flexing of the tubular body along the axisof the downhole. For example, downhole tools having a flexible memberand/or a flexible joint may include those described in U.S. Pat. Nos.6,945,338 and 7,216,726, which are each incorporated herein by referencein their entirety.

The flexible member within the downhole tool of the present disclosuremay provide a point of flexure, in which the point of flexure providesarticulation along the axis of the downhole tool. As such, in one ormore embodiments, the point of flexure for the flexing member isdisposed between or at the location of the stabilizing members of thedownhole tool. For example, as shown in FIG. 3A, the point of flexure333 of the flexible member 331 is disposed at about the location of thesecond stabilizing member 313. However, those having ordinary skill inthe art will appreciate that the point of flexure may also be disposedat about the location of the first stabilizing member 311, or a locationbetween the first stabilizing member 311 and the second stabilizingmember 313, without departing from the scope of the present disclosure.Additionally, while the term “point of flexure” may be understood tomean a single location along the axis of the downhole tool, it should beunderstood that the flexure of flexible member 331 may occur over aregion. For example, flexible member 331 may be characterized as havinga point of flexure that is distributed along a selected axial length ofthe downhole tool rather than a single “point” location.

Referring now to FIG. 4, a perspective view of a downhole tool 401disposed within a string of tubular members 441 in accordance withembodiments disclosed herein is shown. In this embodiment, the downholetool 401, having a first stabilizing member 411 and a second stabilizingmember 413 with a flexible member 431 disposed therein, is attached toand connected within the string of tubular members 441. As shown, thestring of tubular members 441 may include a lower bottom hole assembly443 and an upper bottom hole assembly 445. As such, the string 441 maybe used as a drill string, e.g., in which the lower bottom hole assembly443 includes a drill bit 447 disposed at an end thereof. It should beunderstood that the use of terms “upper” and “lower” is arbitrary inreferring to components of the drill string (and bottom hole assembly).However, by convention, “upper” typically refers to a location placedfarther away from the drill bit than a “lower” location.

While it should be understood that any variety of drill collars,stabilizers, transducers, measurement-while-drilling tools,logging-while-drilling tools, downhole motors (e.g., mud motors), or anycombination thereof may be located within either the upper 445 or lower443 bottom hole assemblies, typically, a lower bottom hole assembly 443includes drilling components (e.g., mud motors, air drilling hammers,etc.) that may be used to facilitate drilling and the upper bottom holeassembly 445 includes ancillary components (e.g., transducers,measurement-while-drilling tools, logging-while drilling tools, etc).

As discussed above, a downhole tool in accordance with embodimentsdisclosed herein may be disposed downhole within a borehole, in whichthe downhole tool may be used to stabilize, or assist in stabilizing,one or more tubular members and/or other downhole tools disposed withinthe borehole. For example, with reference to FIG. 4, the downhole tool401 and the string of tubular members 441 may be disposed downhole todrill within and/or form a borehole within a formation. The string oftubular members 441 may be disposed downhole, in which the drill bit 447may rotated with respect to the borehole to drill at the bottom of theborehole. Drill bit 447 may be rotated by the rig (e.g., top drive orrotary table) and/or downhole motor. During drilling, the firststabilizing member 411 and second stabilizing member 413 may be used tostabilize the downhole tool 401 and the string 441, such as by engaginga wall of the borehole. Particularly, in this embodiment shown, thedownhole tool 401 may have at least two points-of-contact to engage thewall of the borehole, in which one point-of-contact 451 may beestablished by the first stabilizing member 411 engaging the wall of theborehole, and another axially spaced point-of-contact 453 may beestablished by the second stabilizing member 413 engaging the wall ofthe borehole. The points-of-contact with the wall of the borehole may beused to stabilize, or assist in stabilizing, the string of tubularmembers 441 and drill bit 447. Additionally, while the term“point-of-contact” may be understood to mean a single location along thesurface of a stabilizing member of the downhole tool that engages thewall of the borehole, it should be understood that the contact of astabilizing member may occur over a region. For example, the firststabilizing member 411 and/or the second stabilizing member 413 may becharacterized as having a point-of-contact with the wall of the boreholethat is distributed along a selected radial section of the downholetool, rather than a single location with the first stabilizing member411 and/or the second stabilizing member 413.

Flexible member 431 may be used to provide flexure (e.g., bending) alongan axis of the downhole tool 401, thereby enabling the first stabilizingmember 411 and the second stabilizing member 413 to also flex along theaxis. As such, depending on the direction and/or force used by the drillbit 447 to drill, one or both of the first stabilizing member 411 andthe second stabilizing member 413 may engage the borehole wall. Thefirst stabilizing member 411 and the second stabilizing member 413 mayalso provide additional control for the string 441, such as by dampeningvibration and/or flexure within the string 441. For example, theflexible member 431 may have a dampening member disposed therein, inwhich the flexible member 431 may be used to dampen vibration. As such,the flexible member 431 may be used to dampen vibration between thefirst stabilizing member 411 and the second stabilizing member 413within the downhole tool 401 and other portions of the string 441, inaddition to providing flexure between the first stabilizing member 411and the second stabilizing member 413 within the downhole tool 401 andother portions of the string 441.

For example, during use of the string 441 downhole, the drill bit 447may be used to form and/or extend a borehole downhole. During this useof the string 441, the drill bit 447 may generate vibration from thedrilling within the earth formation. As such, the vibration generated bythe drill bit 447 may propagate along the string 441, such as throughthe lower bottom hole assembly 443, and into the downhole tool 401. Tostabilize the string 441, one or both of the stabilizing members 411 and413 may be used to engage the wall of the borehole, in which vibrationreceived by the stabilizing members 411 and 413 may be dampened againstthe wall of the borehole. The vibration that has propagated into andthrough the lower bottom hole assembly 443 may be dampened using thedownhole tool 401, thereby reducing and/or insulating altogether thevibration the upper bottom hole assembly 445 may receive. As such, thedownhole tool 401 may dampen the vibration received by the upper bottomhole assembly 445. Further, to additionally dampen vibration, thedownhole tool 401 may include a dampening member (as discussed above).During use of the string 441, the dampening member may additionallydampen vibration within the downhole tool 401 to reduce and/or insulatealtogether the vibration the upper bottom hole assembly 445 may receive.

Furthermore, as mentioned above, at least one or both of the firststabilizing member 411 and the second stabilizing member 413 may be ableto rotate about the axis of the downhole tool 401 with respect to thetool mandrel (e.g., be rotationally geostationary relative to theborehole). The first stabilizing member 411 may be rotatable withrespect to the second stabilizing member 413, and vice-versa, or, in anembodiment having only one of the stabilizing members (e.g., 411 and413), the body 403 of tool 401. A motor may be disposed within thestring 441, such as within the lower bottom hole assembly 443. A motormay rotate the drill bit 447 and may also rotate the remainder of thelower bottom hole assembly (e.g., if a motor is disposed within thelower bottom hole assembly 443) and/or the second stabilizing member413, e.g., if a stabilizing member is rotationally fixed to the tool401. However, because of the enabled rotation about the axis of thedownhole tool 401 between the first stabilizing member 411 and thesecond stabilizing member 413, the first stabilizing member 411 mayrotate at a slower rate with respect to the second stabilizing member413, or the first stabilizing member 411 may remain substantiallyrotationally stationary with respect to the borehole while the secondstabilizing member 413 is rotating with the lower bottom hole assembly413. As such, the first stabilizing member 411 may remain rotationallystationary during engagement and stabilization with the wall of theborehole, while the second stabilizing member 413 rotates duringengagement and stabilization with the wall of the borehole.Additionally, in an embodiment in which both the first stabilizingmember 411 and the second stabilizing member 413 may be able to rotateabout the axis of the downhole tool 401, the first stabilizing member411 and the second stabilizing member 413 may remain substantiallyrotationally stationary with respect to the borehole while the lowerbottom hole assembly 443 is rotating. In such an embodiment, both thefirst stabilizing member 411 and the second stabilizing member 413 mayremain rotationally stationary during engagement and stabilizing withthe wall of the borehole.

Referring now to FIG. 5, a cross-sectional view of a downhole tool 501in accordance with embodiments disclosed herein is shown. Similar toabove, the downhole tool 501 includes a tubular body 503 having a firstbody portion 507 and a second body portion 509 with a first stabilizingmember 511 and a second stabilizing member 513 disposed thereon,respectively. The first stabilizing member 511 may rotate with respectto the second stabilizing member 513 about an axis 505 of the downholetool 501.

Further, as shown and similar to the embodiments above, the downholetool 501 includes a flexible member 531. However, in this embodiment,rather than having the flexible member 531 disposed at about thelocation of the second stabilizing member 513, the flexible member 531is disposed between the first stabilizing member 511 and the secondstabilizing member 513. Particularly, the depicted flexible member 531is disposed substantially the same distance from the first stabilizingmember 511 and the second stabilizing member 513. As mentioned above,though, those having ordinary skill in the art will appreciate that thelocation of the flexible member within the downhole tool is not solimited, as the flexible member may be disposed at any of the multiplelocations within the downhole tool (e.g., at any location between thefirst and second stabilizing members, at the location of the firststabilizing member, or at a location outside of the section between thefirst and second stabilizing members) without departing from the scopeof the present disclosure.

Additionally, as shown, the flexible member 531 may have an outerdiameter substantially the same as an outer diameter of the remainder ofthe tubular body of the downhole tool, as depicted, excluding thediameter of the stabilizing members. As such, the flexible member 531may have an outer diameter that is smaller than an outer diameter of thefirst stabilizing member 511 and/or the second stabilizing member 513.However, those having ordinary skill in that art will appreciate thatthe diameter of the flexible member may be selected from any of themultiple diameters available within a downhole tool without departingfrom the scope of the present disclosure.

Referring now to FIG. 6, a cross-sectional view of a downhole tool 601in accordance with embodiments disclosed herein is shown. Similar to theabove embodiments, the downhole tool 601 includes a tubular body 603.Further, the downhole tool 601 includes a drill bit 661 disposed at anend thereof, in which the drill bit 661 may be used to drill to form,enlarge, and/or remove earth and/or other material within a borehole. Assuch, in this embodiment, the downhole tool 601 may include a flexiblemember 631, in which the flexible member 631 may have substantially thesame outer diameter as the tubular body 603. Furthermore, the downholetool 601 may include another drill bit 663, in which the drill bit 663may be included and/or attached to the downhole tool 601 adjacent to theflexible member 631.

In the embodiment shown in FIG. 6, and as discussed above, the drill bit661 may be a milling tool, in which the drill bit 661 may be used tomill within a borehole when drilling. Further, the drill bit 663 may bea milling tool and/or a reamer, in which the drill bit 663 may be usedto also mill within the borehole when drilling. Accordingly, a downholetool in accordance with embodiments disclosed herein may include one ormore drill bits and/or drilling tools, in which the drill bits and/ordrilling tools may be one of a number of different tools, devices,and/or components, as discussed above.

In FIG. 6, a deflector 671 is shown disposed within the borehole. Thedeflector 671, which may also be a diverter, a whipstock, and/or mayinclude a concave surface for receiving the downhole tool 601, may beused to deflect the downhole tool 601 when contacting the deflector 671.The angle of deflection may vary, but the deflector 671 may be used todeflect the drill bit 661 of the downhole tool 601 when in contact, andthereby deflect the trajectory of the downhole tool 601 such that thedownhole tool 601 may be used to drill through casing 691 within theborehole and drill within the formation. As such, the flexible member631 may be used to provide flexure and/or dampen vibration when usingthe downhole tool 601, particularly when drilling through the casing 691and into the formation.

Referring now to FIG. 7, a cross-sectional view of a downhole tool 701in accordance with embodiments disclosed herein is shown. The downholetool 701 may include a drill bit 761 disposed at an end thereof, inwhich the drill bit 761 may be used to drill to form, enlarge, and/orremove earth and/or other material within a borehole. Further, thedownhole tool 701 may include a flexible member 731, in which theflexible member 731 may be used to provide flexure and/or dampenvibration when using the downhole tool 701.

Further, as shown in FIG. 7, equipment 773 may be disposed downholewithin the borehole. The equipment 773, which may include a packer, abridge plug, a wellbore flow control device, a wellbore isolationdevice, a tubular member, and/or any other type of equipment that may bedisposed downhole within a borehole, may be impeding the performance ofthe well including the borehole. As such, the downhole tool 701 may beused to drill through the equipment 773, such as mill through theequipment 773, thereby removing the equipment 773 from the borehole.Accordingly, a downhole tool in accordance with one or more embodimentsdisclosed herein may be used to mill to remove equipment from aborehole, in which the flexible member of the tool may be used toprovide flexure and/or dampen vibration when using the downhole tool,particularly when drilling through the equipment disposed downhole.

Referring now to FIG. 8, a cross-sectional view of a downhole tool 801in accordance with embodiments disclosed herein is shown. The downholetool 801 may include a drill bit 861 disposed at an end thereof.Further, the downhole tool 801 may include a stabilizing member 811and/or a flexible member 831. The stabilizing member 811 may be used toprovide stability when using the downhole tool 801, and the flexiblemember 831 may be used to provide flexure and/or dampen vibration whenusing the downhole tool 801.

As such, in this embodiment, the downhole tool 801 may be used to drillthrough the equipment 873, such as mill through the equipment 873, toremove the equipment 873 from the borehole. Accordingly, a downhole toolin accordance with one or more embodiments disclosed herein may be usedto mill to remove equipment from a borehole, in which the stabilitymember and the flexible member of the tool may be used to providestability, flexure and/or dampen vibration when using the downhole tool,particularly when drilling through the equipment disposed downhole.

Referring now to FIG. 9, a cross-sectional view of a downhole tool 901in accordance with embodiments disclosed herein is shown. The downholetool 901 may include a drill bit 961 disposed at an end thereof, and mayfurther include a flexible member 931. Equipment 973 may also bedisposed downhole within the borehole. The equipment 973, in thisembodiment, may include a tubular member disposed downhole within theborehole. As such, the downhole tool 901 may be used to drill throughthe equipment 973, such as mill through the equipment 973, therebyremoving the equipment 973 from the borehole. Accordingly, a downholetool in accordance with one or more embodiments disclosed herein may beused to mill to remove equipment from a borehole, in which the flexiblemember of the tool may be used to provide flexure and/or dampenvibration when using the downhole tool, particularly when drillingthrough the equipment disposed downhole.

Referring now to FIG. 10, a cross-sectional view of a downhole tool 1001in accordance with embodiments disclosed herein is shown. The downholetool 1001 may include a drill bit 1061 disposed at an end thereof, andmay further include a stabilizing member 1011 and/or a flexible member1031. The stabilizing member 1011 may be used to provide stability whenusing the downhole tool 1001, and the flexible member 1031 may be usedto provide flexure and/or dampen vibration when using the downhole tool1001. As discussed above, the downhole tool 1001 may be used to drillthrough the equipment 1073 to remove the equipment 1073 from theborehole. Accordingly, a downhole tool in accordance with one or moreembodiments disclosed herein may be used to mill to remove equipmentfrom a borehole, in which the stability member and the flexible memberof the tool may be used to provide stability, flexure and/or dampenvibration when using the downhole tool, particularly when drillingthrough the equipment disposed downhole.

Referring now to FIG. 11, a cross-sectional view of a downhole tool 1101in accordance with embodiments disclosed herein is shown. The downholetool 1101 includes a tubular body 1103 with a drill bit 1161 disposed atan end thereof. The downhole tool 1101 may further include a firststabilizing member 1111, a second stabilizing member 1113, and/or aflexible member 1131. The stabilizing members 1111 and 1113 may be usedto provide stability when using the downhole tool 1101, such as whendrilling with the downhole tool 1101. Further, the flexible member 1131may be used to provide flexure and/or dampen vibration when using thedownhole tool 1101. As such, the downhole tool 1101 may be used to drillthrough the equipment 1173 to remove the equipment 1173 from theborehole.

As shown in FIG. 11, the first stabilizing member 1111 may be able torotate, such as about an axis of the downhole tool 1101, with respect tothe second stabilizing member 1113. For example, the second stabilizingmember 1113 may be able to rotate with respect to the tubular body 1103of the downhole tool 1101. Accordingly, when drilling with the downholetool 1101, the second stabilizing member 1113 may remain rotationallystationary and/or rotate independently of the first stabilizing member1113 if the first stabilizing member 1111 rotates during the drillingwith the downhole tool 1101. Accordingly, a downhole tool in accordancewith one or more embodiments disclosed herein may include one or morestabilizing members, one or more flexible members, and/or one or moredrill bits included therewith.

Similar to FIG. 11, FIG. 12 shows a cross-sectional view of a downholetool 1201 in accordance with embodiments disclosed herein. As with theabove embodiments, the downhole tool 1201 includes a drill bit 1261disposed at an end thereof and further includes a first stabilizingmember 1211, a second stabilizing member 1213, and/or a flexible member1231. The stabilizing members 1211 and 1213 may be used to providestability when using the downhole tool 1201, and the flexible member1231 may be used to provide flexure and/or dampen vibration. As such,the downhole tool 1201 may be used to drill through the equipment 1273to remove the equipment 1273 from the borehole. Further, the firststabilizing member 1211 may be able to rotate, such as about an axis ofthe downhole tool 1201, with respect to the second stabilizing member1213. Accordingly, a downhole tool in accordance with one or moreembodiments disclosed herein may be used to mill to remove equipmentfrom a borehole, in which the stability member and the flexible memberof the tool may be used to provide stability, flexure and/or dampenvibration when using the downhole tool, particularly when drillingthrough the equipment disposed downhole.

It should also be understood that the present disclosure contemplateshaving other structures and/or arrangements for a downhole tool tostabilize a string of tubular members within a borehole. As shown in theabove embodiments, the downhole tool includes two stabilizing members.However, in another embodiment, more than two stabilizing members may beused within the downhole tool. Further, the downhole tool may includemore than one flexible member, or the flexible member may be disposed atdifferent locations and/or have different arrangements than as shown anddiscussed above. It should also be understood that the presentdisclosure contemplates a method to dampen a downhole assembly whiledrilling (including reaming, etc.). In particular, a downhole tool maybe disposed in a borehole and may include a first stabilizing member, asecond stabilizing member, and a flexible member. The method may includeflexing the flexible member such that the first or the second (ifpresent) stabilizing member contacts the wall of the bore hole anddampens remaining components of the drill string, bottom hole assembly,or drill bit.

Embodiments disclosed herein may provide for one or more of thefollowing advantages. First, embodiments disclosed herein may providefor a downhole tool that may be connected within a string of tubularmembers disposed downhole, in which the downhole tool may engage one ormore surfaces of the borehole. When engaging the surfaces of theborehole, the downhole tool may dampen vibration (e.g., reducevibration) received by the downhole tool. As such, the downhole tool mayprevent damage to the tubular members and/or other downhole toolsdisposed downhole within a borehole and/or attached to a tubular string.Further, embodiments disclosed herein provide for a downhole tool thatmay include at least two stabilizing members. In such embodiments, eachof the stabilizing members may provide a point-of-contact with aborehole wall, thereby providing additional control and direction to astring of tubular members, such as during drilling.

While the present disclosure has been described with respect to alimited number of embodiments, those skilled in the art, having benefitof this disclosure, will appreciate that other embodiments may bedevised which do not depart from the scope of the disclosure asdescribed herein. Accordingly, the scope of the invention should belimited only by the attached claims.

1. A method to abate vibration during drilling within a borehole, themethod comprising: connecting a downhole tool to a string of tubularmembers, the string of tubular members having a drill bit disposed atone end; disposing the downhole tool having an axis defined therethroughwithin the borehole, the downhole tool comprising a first stabilizingmember, a second stabilizing member, and a flexible member; flexing theflexible member such that at least one of the first stabilizing memberand the second stabilizing member contacts a wall of the borehole; anddrilling into the borehole with the drill bit.
 2. The method of claim 1,wherein the drilling into the borehole comprises at least one of:rotating the string of tubular members with a drill rig such that thedrill bit rotates with respect to the borehole; and rotating the drillbit with a mud motor such that the drill bit rotates with respect to theborehole.
 3. The method of claim 1, further comprising: rotating thefirst stabilizing member and the second stabilizing member with respectto each other about the axis.
 4. The method of claim 1, furthercomprising: rotating at least one of the first stabilizing member andthe second stabilizing member with respect to the drill bit such thatthe at least one of the first stabilizing member and the secondstabilizing member remains substantially rotationally stationary withrespect to the borehole.
 5. The method of claim 1, further comprising:dampening the flexing of the flexible member.
 6. The method of claim 1,further comprising: providing the downhole tool with a dampening member.7. The method of claim 6, wherein the dampening member dampens vibrationto a level such that damage is prevented to a sensor connected to thestring of tubular members.
 8. The method of claim 1, wherein the stringof tubular members comprises a lower bottom hole assembly and an upperbottom hole assembly, wherein the downhole tool is connected to thestring of tubular members between the lower bottom hole assembly and theupper bottom hole assembly.
 9. The method of claim 1, wherein at leastone of the first stabilizing member and the second stabilizing membercomprises a dampening member.
 10. A method to abate vibration duringdrilling within a borehole, the method comprising: connecting a downholetool to a string of tubular members, the string of tubular membershaving a drill bit disposed at one end; disposing the downhole toolhaving an axis defined therethrough within the borehole, the downholetool comprising a first stabilizing member and a flexible member;flexing the flexible member such that the first stabilizing membercontacts a wall of the borehole; and drilling into the borehole with thedrill bit.
 11. The method of claim 10, further comprising: rotating thefirst stabilizing member with respect to the flexible member.
 12. Themethod of claim 10, further comprising: rotating the first stabilizingmember with respect to the drill bit such that the first stabilizingmember remains substantially rotationally stationary with respect to theborehole.
 13. The method of claim 10, further comprising: dampening theflexing of the flexible member.
 14. The method of claim 10, wherein thedownhole tool further comprises a dampening member.
 15. The method ofclaim 10, wherein the first stabilizing member comprises a dampeningmember.
 16. The method of claim 10, wherein the drilling into theborehole with the drill bit comprises milling the borehole with thedrill bit, thereby removing at least a portion of material disposedwithin the borehole.
 17. The method of claim 10, wherein the drill bitcomprises one of a roller-cone drill bit, a shearing drill bit, a rockbit, a PDC bit, a reamer, and a milling tool.
 18. A method to abatevibration during drilling within a borehole, the method comprising:connecting a downhole tool to a string of tubular members, the string oftubular members having a drill bit disposed at one end; disposing thedownhole tool having an axis defined therethrough within the borehole,the downhole tool comprising a first stabilizing member and a firstdampening member; providing the downhole tool with a second dampeningmember; and drilling into the borehole with the drill bit.
 19. Themethod of claim 18, wherein the downhole tool further comprises aflexible member.
 20. The method of claim 18, wherein the first dampeningmember is axially spaced from the second dampening member.
 21. Adownhole tool to abate vibration during drilling, comprising: agenerally tubular body having an axis defined therethrough; a firststabilizing member disposed at a first location on the tubular body; asecond stabilizing member disposed at a second location on the tubularbody, wherein the first stabilizing member and the second stabilizingmember are rotatable with respect to each other about the axis; and aflexible member disposed within the tubular body such that the firststabilizing member and the second stabilizing member are configured toarticulate with respect to each other along the axis.
 22. The downholetool of claim 21, further comprising a dampening member disposed withinthe tubular body and configured to dampen vibration received by thedownhole tool.
 23. The downhole tool of claim 21, wherein the flexiblemember comprises a dampening member configured to dampen flexure of theflexible member.
 24. The downhole tool of claim 23, wherein one of thefirst stabilizing member and the second stabilizing member comprises thedampening member.
 25. The downhole tool of claim 24, wherein thedampening member comprises an elastomeric member.
 26. The downhole toolof claim 21, wherein one of the first stabilizing member and the secondstabilizing member comprises a plurality of bladed members.
 27. Thedownhole tool of claim 26, wherein at least one of the plurality ofbladed members comprises an elastomeric material.
 28. The downhole toolof claim 21, wherein the generally tubular body comprises a first bodyportion and a second body portion, wherein the first stabilizing memberis disposed on the first body portion and the second stabilizing memberis disposed on the second body portion.
 29. The downhole tool of claim28, wherein at least one component of the flexible member is disposedwithin the second body portion.
 30. The downhole tool of claim 28,wherein the second body portion comprises a first body member and asecond body member, wherein the flexible member is disposed between thefirst body member and the second body member.
 31. The downhole tool ofclaim 30, wherein the flexible member comprises an elastomeric member.32. The downhole tool of claim 21, wherein a maximum outer diameter ofone of the first stabilizing member and the second stabilizing member isgreater than a maximum outer diameter of the other of the firststabilizing member and the second stabilizing member.
 33. A downholetool to abate vibration during drilling, the downhole tool having anaxis defined therethrough to be disposed within a borehole, comprising:a first stabilizing member disposed at a first location; and a secondstabilizing member disposed at a second location; wherein the firststabilizing member and the second stabilizing member are rotatable withrespect to each other about the axis, and wherein the first stabilizingmember and the second stabilizing member are each configured to engage awall of the borehole.
 34. The downhole tool of claim 33, furthercomprising: a flexible member disposed within a tubular member of thedownhole tool such that the first stabilizing member and the secondstabilizing member are configured to articulate with respect to eachother along the axis.
 35. The downhole tool of claim 34, wherein theflexible member comprises an elastomeric member.
 36. The downhole toolof claim 33, wherein the flexible member comprises a dampening memberconfigured to dampen flexure of the flexible member.
 37. The downholetool of claim 33, further comprising: a dampening member disposed withina tubular member of the downhole tool such that the dampening member isconfigured to dampen vibration received within the downhole tool. 38.The downhole tool of claim 33, wherein at least one of the firststabilizing member and the second stabilizing member comprises adampening member.
 39. A system to abate vibration during drilling, thesystem having an axis defined therethrough to be disposed within aborehole, the system comprising: a downhole tool having a first end anda second end, comprising: a first stabilizing member having a dampeningmember disposed thereon; a second stabilizing member, wherein the firststabilizing member and the second stabilizing member are rotatable withrespect to each other about the axis; and a flexible member disposedwithin the tubular member such that the first stabilizing member and thesecond stabilizing member are configured to articulate with respect toeach other along the axis; and an upper bottom hole assembly having afirst end and a second end, wherein the second end of the upper bottomhole assembly is connected to the first end of the downhole tool; and alower bottom hole assembly having a first end and a second end, whereinthe first end of the lower bottom hole assembly is connected to thesecond end of the downhole tool.
 40. The system of claim 39, wherein adrill bit is connected to the second end of the lower bottom holeassembly.
 41. The system of claim 39, wherein the upper bottom holeassembly comprises a sensor.
 42. A method to abate vibration duringdrilling within a borehole, the method comprising: connecting a downholetool to a string of tubular members, the string of tubular membershaving a drill bit disposed at one end; disposing the downhole toolhaving an axis defined therethrough within the borehole, the downholetool comprising a flexible member; drilling into the borehole with thedrill bit; and flexing the flexible member when drilling with the drillbit.
 43. The method of claim 42, wherein the downhole tool furthercomprises a first stabilizing member, wherein the flexing the flexiblemember comprises flexing the flexible member such that the firststabilizing member contacts a wall of the borehole.
 44. The method ofclaim 43, further comprising: rotating the first stabilizing member withrespect to the flexible member.
 45. The method of claim 43, wherein thedownhole tool further comprises a second stabilizing member.
 46. Themethod of claim 43, further comprising: rotating the first stabilizingmember with respect to the second stabilizing member.
 47. The method ofclaim 42, further comprising: dampening the flexing of the flexiblemember.
 48. The method of claim 42, wherein the drill bit comprises amilling tool, wherein the drilling into the borehole with the drill bitcomprises milling the borehole with the milling tool.
 49. The method ofclaim 42, wherein the drill bit comprises one of a roller-cone drillbit, a shearing drill bit, a rock bit, a PDC bit, a reamer, and amilling tool.
 50. A downhole tool to abate vibration during drilling,comprising: a generally tubular body having an axis definedtherethrough; a drill bit connected to the tubular body at an endthereof; and a flexible member disposed within the tubular body suchthat the drill bit is configured to articulate with respect to the axisof the tubular body.
 51. The downhole tool of claim 50, furthercomprising: a first stabilizing member disposed at a first location onthe tubular body, wherein the first stabilizing member is configured toarticulate with respect to the axis of the tubular body.
 52. Thedownhole tool of claim 51, further comprising: a second stabilizingmember disposed at a second location on the tubular body, wherein thefirst stabilizing member and the second stabilizing member are rotatablewith respect to each other about the axis.
 53. The downhole tool ofclaim 50, wherein the flexible member comprises a dampening memberconfigured to dampen flexure of the flexible member.
 54. The downholetool of claim 50, further comprising: a dampening member disposed withina tubular member of the downhole tool such that the dampening member isconfigured to dampen vibration received within the downhole tool. 55.The downhole tool of claim 50, wherein the drill bit comprises one of aroller-cone drill bit, a shearing drill bit, a rock bit, a PDC bit, areamer, and a milling tool.